US6896056B2 - System and methods for detecting casing collars - Google Patents

System and methods for detecting casing collars Download PDF

Info

Publication number
US6896056B2
US6896056B2 US10/156,399 US15639902A US6896056B2 US 6896056 B2 US6896056 B2 US 6896056B2 US 15639902 A US15639902 A US 15639902A US 6896056 B2 US6896056 B2 US 6896056B2
Authority
US
United States
Prior art keywords
signal
casing
tubing
depth
casing collar
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Expired - Fee Related, expires
Application number
US10/156,399
Other languages
English (en)
Other versions
US20030010495A1 (en
Inventor
Luis Mendez
Darrin Willauer
James R. Bridges
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Baker Hughes Holdings LLC
Original Assignee
Baker Hughes Inc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Baker Hughes Inc filed Critical Baker Hughes Inc
Priority to US10/156,399 priority Critical patent/US6896056B2/en
Assigned to BAKER HUGHES INCORPORATED reassignment BAKER HUGHES INCORPORATED ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: MENDEZ, LUIS, BRIDGES, JAMES R., WILLAUER, DARRIN
Publication of US20030010495A1 publication Critical patent/US20030010495A1/en
Application granted granted Critical
Publication of US6896056B2 publication Critical patent/US6896056B2/en
Adjusted expiration legal-status Critical
Expired - Fee Related legal-status Critical Current

Links

Images

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
    • E21B47/14—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/09—Locating or determining the position of objects in boreholes or wells, e.g. the position of an extending arm; Identifying the free or blocked portions of pipes
    • E21B47/092—Locating or determining the position of objects in boreholes or wells, e.g. the position of an extending arm; Identifying the free or blocked portions of pipes by detecting magnetic anomalies

Definitions

  • the present invention relates generally to oilwell casing string joint locators, and more particularly, to a joint locator and methods for positioning a well tool connected to a length of coiled or jointed tubing in a well.
  • a wellbore is drilled into a subsurface producing formation.
  • a string of casing pipe is then cemented into the wellbore.
  • An additional string of pipe commonly known as production tubing, may be disposed within the casing string and is used to conduct production fluids out of the wellbore.
  • the downhole string of casing pipe is comprised of a plurality of pipe sections which are threadedly joined together.
  • the pipe joints also referred to as collars, have increased mass as compared to the pipe sections.
  • the logging tools used include a pipe joint locator whereby the depths of each of the pipe joints through which the logging tools are passed is recorded.
  • the logging tools generally also include a gamma ray logging device which records the depths and the levels of naturally occurring gamma rays that are emitted from various well formations.
  • the casing collar and gamma ray logs are correlated with previous open hole logs which results in a very accurate record of the depths of the pipe joints across the subterranean zones of interest and is typically referred to as the joint and tally log.
  • tubing refers to either coiled or jointed tubing.
  • the depth of a particular casing pipe joint adjacent or near the desired location at which the tool is to be positioned can readily be found on the previously recorded joint and tally log for the well. Given this readily available pipe joint depth information, it would seem to be a straightforward task to simply lower the well tool connected to a length of tubing into the casing while measuring the length of tubing inserted in the casing.
  • Measuring could be performed by means of a conventional surface tubing measuring device.
  • the tool is lowered until the measuring device reading equals the depth of the desired well tool location as indicated on the joint and tally log.
  • the true depth measurement is flawed due to effects such as tubing stretch, elongation due to thermal expansion, sinusoidal and helical buckling of the tubing, and a variety of other unpredictable deformations in the length of the tubing from which the tool is suspended in the wellbore.
  • coiled tubing tends to spiral when forced down a well or through a horizontal section of a well.
  • a variety of pipe string joint indicators have been developed including slick line indicators that can produce drag inside the pipe string and wire line indicators that send an electronic signal to the surface by way of electric cable and others. These devices, however, either cannot be utilized as a component in a coiled tubing system or have disadvantages when so used.
  • Wireline indicators do not work well in highly deviated holes because they depend on the force of gravity to position the tool. In addition, the wire line and slick line indicators take up additional rig time when used with jointed tubing.
  • the present invention provides a casing collar locator system and methods of using the casing collar locator system which overcomes the other shortcomings of the prior art.
  • the casing collar locator system of the present invention comprises a casing collar locator tool adapted to be attached to the end of a length of coiled or jointed tubing and moved within a pipe string as the tubing is lowered or raised therein.
  • the casing collar locator tool is adapted to connect to other downhole tools which may include packers and perforating guns.
  • a sensing system is disposed in the casing collar locator tool for detecting the increased mass of a pipe casing collar as the locator is moved through the pipe casing collar and for generating an electric output signal in response thereto.
  • An electronic system detects the sensor electric signal and activates an acoustic signal generator to create a surface detectable acoustic signal transmitted through the coiled or jointed tubing related to the location of the pipe casing collar.
  • a surface receiver detects the acoustic signal and transmits the signal to a surface processor.
  • a surface processor receives a continuous signal from a surface tubing depth measuring system and correlates the depth measurement with the received acoustic signals and stores this information to provide graphical and tabular outputs representative of the casing collar locations.
  • the casing collar locator tool is programmed at the surface, before insertion into the wellbore, to store the casing collar indication in downhole memory and to transmit the information to the surface after a programmed time delay has expired.
  • a surface acoustic transducer system is adapted to send acoustic command signals to and receive acoustic signals from an acoustic casing collar tool.
  • the casing collar tool is adapted to receive the surface generated command signals and to thereby act according to instructions in the processor of the casing collar tool.
  • the methods basically comprise connecting a casing collar locator tool of this invention to the end of a length of tubing.
  • the casing collar locator automatically generates a surface detectable acoustic signal in the tubing each time the casing collar locator moves through a pipe casing collar.
  • the depth of the casing collar locator and the surface acoustic signal detector are continuously measured, and the measured depths of the casing collar locator corresponding to the detected acoustic signal are recorded to produce an accurate record of the depth of each detected casing collar.
  • the casing collar tool is programmed at the surface to store acquired casing collar data in downhole memory and to transmit this data to the surface after a programmed time delay.
  • the casing collar tool is attached to the end of a length of coiled or jointed tubing and the tubing is run into the hole.
  • the casing collar sensor As the tool is passed through each casing collar, the casing collar sensor generates an electrical signal which is stored in downhole memory as a function of time.
  • a surface depth sensor measures and transmits this depth data to a surface processor. After a surface programmed time delay has expired the data in downhole memory is acoustically transmitted to the surface as a function of time, detected by the surface receiver and sent to the surface processor.
  • the surface processor generates casing collar depth information according to programmed instructions.
  • a prior casing collar log is entered into the downhole tool memory along with a desired predetermined location as indicated by the number of collars traversed.
  • the casing collar tool is run into the hole and senses each collar traversed. When the number of collars traversed matches the predetermined location, the tool transmits a signal to the surface, thereby allowing accurate tool placement downhole.
  • a method for determining the location of downhole production elements is described.
  • Existing casing collar sensor signatures of various production elements are stored in a memory module of a signal processor in the acoustic casing collar locator tool.
  • the signatures are unique to each kind of element such as packers, valves, gravel pack screens, and other production elements.
  • the casing collar tool is run in the hole on a tubing string moves past a production element, thereby generating an electric signal from the casing collar sensor.
  • the casing collar sensor signal is compared to the stored signature signals using a technique such as cross correlation thereby determining the type of downhole element sensed.
  • the locator tool sends an encoded acoustic signal to the surface indicating the unique element sensed.
  • the surface system correlates the downhole signal and a surface measured depth signal to develop a log of downhole production elements.
  • a method for locating a well tool by using a downhole production element as a locating benchmark.
  • a specific element signature is loaded into the memory of the signal processor of the casing collar locator tool.
  • the locator tool and a well tool are run into the hole.
  • an acoustic signal is transmitted to the surface.
  • the well tool may then be positioned a predetermined distance from the located production element.
  • FIG. 1 is a schematic illustration of a system for detecting casing collars in a wellbore and acoustically transmitting this information through a tubing string, according to one embodiment of the present invention
  • FIG. 2 is a schematic illustration of a downhole tool for detecting casing collars according to one embodiment of the present invention
  • FIG. 3 is a schematic illustration of a surface receiver according to one embodiment of the present invention.
  • FIG. 4 is a schematic illustration of a surface receiver according to another embodiment of the present invention.
  • FIG. 5 is a schematic illustration of a surface receiver according to another embodiment of the present invention.
  • FIG. 6 is a schematic illustration a system for detecting casing collars incorporating two-way communication, according to one embodiment of the present invention.
  • tubing refers to either a coiled tubing string or a threadedly jointed tubing string.
  • Coiled tubing is a relatively small flexible tubing (commonly 1-3 inches in diameter), which can be stored on a reel.
  • injector mechanism pulls the tubing from the reel, straightens the tubing and injects it into the well through a seal assembly at the wellhead.
  • the injector mechanism injects thousands of feet of the coiled tubing into the casing string of the well.
  • a fluid may be circulated through the coiled tubing for operating the well tool or for other purposes.
  • the coiled tubing injector at the surface is used to raise and lower the coiled tubing and the well tool during the downhole operations.
  • the injector also removes the coiled tubing and the well tool as the tubing is rewound on the reel at the end of the downhole operations.
  • well 5 is schematically illustrated along with a coiled tubing injector 40 and a coiled tubing reel assembly 10 .
  • the well 5 includes a wellbore 15 having a string of casing 20 cemented therein in the usual manner.
  • the wellbore 15 is typically filled with a completion fluid 17 for maintaining adequate bottom hole pressure on any open hole sections.
  • a length of coiled tubing 25 is inserted into the casing 20 .
  • the coiled tubing 25 has an acoustic casing collar locator tool 35 attached to the bottom of the coiled tubing 25 .
  • a well tool 55 is attached to the bottom of the acoustic casing collar locator 35 .
  • the positions of the well tool 55 and the locator tool 35 may be interchanged without affecting the system operation.
  • more than one well tool 55 may be attached to the locator tool 35 , either above or below the locator tool 35 .
  • a string of jointed production tubing (not shown) may be installed inside the casing 20 , and the acoustic casing collar locator 35 run inside the production tubing.
  • the coiled tubing injector 40 is of a design known to those skilled in the art and functions to straighten the coiled tubing and inject it into the wellbore 15 by way of the wellhead 45 .
  • a depth measuring sensor 60 which may be a depth wheel known in the art, functions to continuously measure the length of the coiled tubing within the wellbore 15 and to provide that information to a surface processor 65 by way of depth cable 70 .
  • the term depth refers to the measured depth or length of tubing inserted in the well. Those skilled in the art will realize that the measured depth, and hence the length of tubing, may be different from the vertical depth for wellbores that deviate from the vertical. Such deviated wellbores are common.
  • the surface processor 65 may be a computer, or microprocessor, with memory capable of running programmed instructions.
  • the processor 65 may also have permanent data storage and hard copy output capabilities.
  • the surface processor 65 functions to continuously record the depth of the coiled tubing 25 and the acoustic casing collar locator 35 attached thereto. This depth information may also be recorded as a function of time and stored in the processor 65 .
  • the processor 65 may be a stand alone unit or may be located in an enclosure attached to a coiled tubing skid (not shown) or truck (not shown) or any other suitable enclosure commonly used in the art.
  • jointed tubing may be used with a conventional derrick system (not shown) to run the casing collar locator tool and a well tool into the hole.
  • the casing collar locator and well tools are attached to the bottom of the jointed tubing and run into the hole.
  • the jointed system may be operated the same as the coiled system with the exception of making up the jointed connections.
  • the acoustic casing collar locator 35 comprises a cylindrical mandrel 135 with a through bore to allow undisturbed flow through the coiled tubing 25 to the well tool 55 .
  • the upper end of the mandrel 135 is adapted to connect to the lower end of the coiled tubing 25 .
  • the ends of the mandrel are adapted to connect to the tubing 25 or the well tools 55 as required for a given operation.
  • the multiple well tools 55 and the collar locator 35 may be attached to the end of the tubing 25 in any order suitable to carry out a particular operation.
  • a housing 130 is adapted to sealably fit over the mandrel 135 and threadably engage a shoulder of the mandrel 135 , thereby creating an annular instrument section 155 between the mandrel 135 and the housing 130 which is sealed from fluid intrusion at either end by conventional elastomeric type seals (not shown).
  • the casing collar sensor 125 is a magnetic device, known to those skilled in the art, for detecting the increased mass of a casing collar 30 as the casing collar sensor 125 is moved through a casing collar 30 joint section.
  • the casing collar sensor 125 generates an electric output signal in response to the increased mass of the casing collar 30 . This electrical signal is sensed by suitable circuitry in the signal processor section 115 .
  • the signal processor 115 contains analog and digital circuitry (not shown), which may include a microprocessor and memory, adapted to power and sense the output of the casing collar sensor 125 and to store this information in the memory of the signal processor 115 .
  • the signal processor 115 is in turn connected by electric wires (not shown), to the drive circuit 110 .
  • the drive circuit 110 receives power from the battery pack 120 via electric wires (not shown).
  • the battery pack is comprised of a plurality of batteries (not shown).
  • the drive circuit 110 provides a signal adapted to properly actuate the acoustic signal generator 105 via electric wires, (not shown).
  • the acoustic signal generator 105 consists of a plurality of piezoelectric ceramic elements 107 configured to impart an acoustic impulse to the mandrel 135 when the acoustic signal generator 105 is actuated by the drive circuit 110 .
  • magnetostrictive elements may be used to impart an acoustic signal into the tubing.
  • the acoustic signal is transmitted through the coiled tubing 25 to the surface where, in one preferred embodiment, it is detected by acoustic signal receiver 50 disposed proximate the injector 40 such that the receiver 50 contacts the coiled tubing 25 as the coiled tubing 25 passes through the injector 40 , as described later.
  • the signal processor 115 may be programmed to generate a pulse type signal or a continuous signal of predetermined frequency. The frequency may be selected depending on operational parameters such as depth, tubing size, coiled or jointed tubing or other pertinent parameters.
  • the receiver 50 comprises a housing 201 that contains rolling elements 205 which are forced in contact with the coiled tubing 25 as it is injected in or out of the wellbore 15 lined with casing 20 .
  • the rolling elements 205 may be spheres, cylindrical rollers, or wheels coupled to actuators 202 for holding the rolling elements 205 against the coiled tubing 25 .
  • the actuators 202 may be mechanically, pneumatically, or hydraulically actuated.
  • Attached to the housing 201 is an accelerometer 215 for sensing vibrations.
  • the acoustic signal, transmitted through the coiled tubing causes a vibrational response in the rolling elements 205 .
  • the vibrational response is transmitted through the housing 201 and is sensed by the accelerometer 215 .
  • the accelerometer 215 generates an electrical signal related to the transmitted acoustic signal from downhole.
  • the accelerometer signal is conditioned and transmitted to the surface processor 65 .
  • the acoustic signals are detected at the surface by receiver assembly 300 which is acoustically coupled to the coiled tubing 25 .
  • the receiver assembly 300 comprises an enclosed fluid-filled reservoir 303 with end caps 306 , 307 which are each fitted with seals 302 suitable for moving the coiled tubing 25 through the reservoir 303 with minimal fluid leakage through the seals 302 . Any suitable sliding seal, including packing materials, known in the art maybe used.
  • the coiled tubing 25 is in contact with the fluid 304 inside the reservoir 303 .
  • the fluid may be water or any other fluid capable of transmitting acoustic energy.
  • the acoustic signals traveling through the coiled tubing 25 are acoustically coupled to the fluid 304 in the reservoir 303 such that the acoustic signal in the coiled tubing 25 generates a pressure signal in the fluid 304 related to the acoustic signal in the coiled tubing 25 .
  • a hydrophone 301 is positioned in the fluid 304 in the reservoir 303 to sense the acoustic related pressure signal in the fluid 304 and transmit an electrical signal to the surface processor 65 related to the pressure signal.
  • the acoustic signal to pressure signal coupling efficiency is relatively low requiring a high sensitivity device such as hydrophone 301 to detect the pressure signal.
  • a hydrophone 400 is located in the wellbore fluid 17 in the annular space between the coiled tubing 25 and the casing 20 such that the hydrophone 400 can sense the acoustic related pressure signals coupled to the wellbore fluid 17 from the coiled tubing 25 as the acoustic signal travels in the coiled tubing past the hydrophone 400 location.
  • the hydrophone 400 transmits an electrical signal related to the pressure signal to the surface processor 65 .
  • the acoustic signal sensed by any of the previously described receivers is transmitted to the surface processor 65 via signal cable 75 .
  • Signal cables 70 and 75 may be electrical, optical, or pneumatic type cables. Alternatively, wireless transmitters may be employed.
  • Surface processor 65 continuously monitors the depth signal generated and transmitted to the processor 65 by the depth sensor 60 .
  • the processor 65 operates according to programmed instructions to correlate the received acoustic signal with the depth of the acoustic casing collar locator 35 as measured by the depth sensor 60 .
  • the depth-casing joint information is stored and/or printed out in graphical and tabular format as a log for use in operations. Alternatively, prior depth logs may be stored in the memory of the surface processor 65 and the stored collar locations compared to the detected collar locations for determining an accurate downhole tool placement between collars.
  • a two-way surface acoustic transducer system 600 and a downhole acoustic casing collar locator 95 are both adapted to operate as transmitters and receivers to provide two-way communication between the surface and the downhole casing collar locator 95 .
  • the two-way surface system 600 comprises a receiver 602 , which may be any of the previously described receivers, and an acoustic transmitter 601 .
  • the acoustic transmitter may be a clamp on device using piezoelectric elements or alternatively magnetostrictive elements for imparting an acoustic signal into the coiled tubing 25 . The rest of the system is as described previously.
  • the surface processor 65 acts according to programmed instructions to direct the acoustic transducer system 90 to send commands to the downhole casing collar locator 95 .
  • the downhole locator tool 95 may have additional receiver elements (not shown) and circuits (not shown) to enable enhanced reception of surface generated signals.
  • the locator 95 acts according to programmed instructions in the downhole processor 115 .
  • Typical surface to downhole commands include but are not limited to commands to (a) initiate transmission of downhole stored data, (b) transmit the number of collars traversed, (c) transmit when a particular production element is identified, (d) change downhole operating modes, for example, from the storage only mode to the transmission at every collar mode, and (e) changing acoustic transmission frequency to improve surface reception.
  • a gamma ray sensor (not shown) and associated circuits (not shown) for detecting natural gamma rays emitted from the subterranean formations may be included in the downhole system.
  • the hydrocarbon bearing formations show increased gamma ray emission over non-hydrocarbon bearing zones. This information is used to identify the various production zones for setting production tools.
  • Any gamma detector known in the art may be used, including, but not limited to, scintillation detectors and geiger tube detectors.
  • the gamma ray detector may be incorporated in the instrument section 155 , or alternatively may be housed in a separate sub (not shown) and connected mechanically and electrically with the casing collar locator 35 using techniques known in the art.
  • the method of this invention for accurately determining the position of casing collars in a wellbore while moving coiled or jointed tubing within the casing comprises the following steps.
  • An acoustic casing collar locator 35 is connected to the bottom end of coiled or jointed tubing 25 prior to running the tubing into the casing 20 in wellbore 15 .
  • the tubing 25 with the acoustic casing collar locator 35 attached is run into the casing 20 and moved therethrough.
  • the acoustic casing collar locator 35 senses the casing collar 30 and transmits an acoustic signal through the tubing 25 to the surface where it is detected by the surface receiver 50 .
  • the surface receiver 50 transmits an electrical signal to the surface processor 65 indicating the reception of the acoustic signal.
  • the depth of the acoustic casing collar locator 35 is continuously measured by the depth sensor 60 and transmitted to the surface processor 65 .
  • the surface processor 65 stores the received casing collar indication as a function of the depth indicated by the depth sensor 60 .
  • the length of each tubing joint can be manually entered into the surface processor 65 .
  • the correlated casing collar depth information can be output in tabular or graphical format for use by the operator.
  • An alternative method comprises the steps of, programming the downhole signal processor 115 to store the detected casing collar signal as a function of time in memory in the signal processor 115 . Presetting the signal processor 115 at the surface to transmit the data after a preset time delay from starting downhole. Running the acoustic casing collar locator 35 into the hole to the approximate depth of interest quickly and then traversing the acoustic casing collar locator 35 through the section of interest at a slower rate. Storing the signal indicating detection of the casing collars in downhole memory as a function of time. Concurrently measuring and storing depth data from the depth sensor 60 in the surface processor 65 as a function of time.
  • Another alternative method comprises, determining from a prior casing collar log, the number of collars to be traversed to a predetermined location. Storing the number of collars in the memory of the downhole signal processor 115 . Preprogramming the acoustic casing collar locator 35 to send a signal when the predetermined number of collars 30 are sensed. Running the acoustic casing collar locator 35 into the hole and sensing the casing collars as the casing collar locator 35 moves past each collar 30 . Comparing the number of collars 30 sensed with the predetermined number in the downhole memory and sending a signal to the surface when the predetermined number of collars is equaled. Using the signal that a predetermined collar 30 is reached, to switch to a mode of transmitting a signal as each additional collar is traversed, thereby allowing an operator to accurately set a downhole tool 55 between collars 30 .
  • a casing collar locator tool is used to acquire the casing collar sensor signals as the sensor passes various distinctive downhole production elements, which include but are not limited to control valves, packers, gravel pack screens, and lateral kickoff hardware.
  • the differences in geometries and relative masses of these downhole elements results in unique casing collar sensor signals, also called signatures, for each type of element.
  • These element signatures may be stored in the memory of the downhole signal processor 115 of the casing collar locator 35 described previously.
  • These signature signals are compared to the signals generated as the casing collar locator tool 35 is moved through the casing 20 using cross correlation or other signal comparison techniques known in the art.
  • the locator tool 35 sends a coded signal to the surface indicating which production element has been sensed. Techniques for encoding acoustic signals are well known in the art and are not discussed here further.

Landscapes

  • Physics & Mathematics (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Geophysics (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Acoustics & Sound (AREA)
  • Remote Sensing (AREA)
  • Geophysics And Detection Of Objects (AREA)
  • Investigating Or Analyzing Materials By The Use Of Ultrasonic Waves (AREA)
  • Length Measuring Devices Characterised By Use Of Acoustic Means (AREA)
  • Examining Or Testing Airtightness (AREA)
US10/156,399 2001-06-01 2002-05-28 System and methods for detecting casing collars Expired - Fee Related US6896056B2 (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
US10/156,399 US6896056B2 (en) 2001-06-01 2002-05-28 System and methods for detecting casing collars

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
US29543601P 2001-06-01 2001-06-01
US34303901P 2001-12-20 2001-12-20
US10/156,399 US6896056B2 (en) 2001-06-01 2002-05-28 System and methods for detecting casing collars

Publications (2)

Publication Number Publication Date
US20030010495A1 US20030010495A1 (en) 2003-01-16
US6896056B2 true US6896056B2 (en) 2005-05-24

Family

ID=26969127

Family Applications (1)

Application Number Title Priority Date Filing Date
US10/156,399 Expired - Fee Related US6896056B2 (en) 2001-06-01 2002-05-28 System and methods for detecting casing collars

Country Status (6)

Country Link
US (1) US6896056B2 (fr)
AU (1) AU2002313629B2 (fr)
CA (1) CA2448895C (fr)
GB (1) GB2393201B (fr)
NO (1) NO20035271D0 (fr)
WO (1) WO2002099250A1 (fr)

Cited By (46)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20040246141A1 (en) * 2003-06-03 2004-12-09 Tubel Paulo S. Methods and apparatus for through tubing deployment, monitoring and operation of wireless systems
US20050121253A1 (en) * 2003-12-08 2005-06-09 John Stewart Through tubing real time downhole wireless gauge
US20050173639A1 (en) * 1999-12-23 2005-08-11 Frederick Larry D. Geosteering of solid mineral mining machines
US20060005965A1 (en) * 2004-07-08 2006-01-12 Christian Chouzenoux Sensor system
US20060081380A1 (en) * 2003-12-15 2006-04-20 Hoffman Corey E Collar locator for slick pump
US20060157250A1 (en) * 2004-12-23 2006-07-20 Remote Marine Systems Limited Improvements In or Relating to Sub Sea Control and Monitoring
US20070044958A1 (en) * 2005-08-31 2007-03-01 Schlumberger Technology Corporation Well Operating Elements Comprising a Soluble Component and Methods of Use
US20070227225A1 (en) * 2006-03-28 2007-10-04 Newman Frederic M Method and system for calibrating a tube scanner
US20080035335A1 (en) * 2006-03-27 2008-02-14 Newman Frederic M Method and system for evaluating and displaying depth data
US20080035333A1 (en) * 2006-03-27 2008-02-14 Newman Frederic M Method and system for scanning tubing
US20080089175A1 (en) * 2006-10-12 2008-04-17 Antech Limited Well downhole condition signalling
US20080164025A1 (en) * 2007-01-10 2008-07-10 Baker Hughes Incorporated System and Method for Determining the Rotational Alignment of Drillstring Elements
US20080257546A1 (en) * 2006-09-20 2008-10-23 Baker Hughes Incorporated Autonomous Downhole Control Methods and Devices
US7571054B2 (en) 2006-03-27 2009-08-04 Key Energy Services, Inc. Method and system for interpreting tubing data
US20100000730A1 (en) * 2008-07-03 2010-01-07 Vetco Gray Inc. Acoustically Measuring Annulus Probe Depth
US20110083845A1 (en) * 2009-10-09 2011-04-14 Impact Guidance Systems, Inc. Datacoil™ Downhole Logging System
US20110147007A1 (en) * 2009-12-22 2011-06-23 Baker Hughes Incorporated Downhole-Adjustable Flow Control Device for Controlling Flow of a Fluid Into a Wellbore
US20110290011A1 (en) * 2008-10-03 2011-12-01 Najmud Dowla Identification of casing collars while drilling and post drilling using lwd and wireline measurements
US8183163B2 (en) 2006-09-12 2012-05-22 Kabushiki Kaisha Toshiba Etching liquid, etching method, and method of manufacturing electronic component
WO2012082302A1 (fr) * 2010-12-17 2012-06-21 Exxonmobil Upstream Research Company Procédé de commande et de positionnement automatiques d'outils autonomes de fond de trou
US8220554B2 (en) 2006-02-09 2012-07-17 Schlumberger Technology Corporation Degradable whipstock apparatus and method of use
WO2013036852A1 (fr) * 2011-09-07 2013-03-14 Halliburgton Energy Services, Inc. Systèmes et procédés de localisateur de joints de tubage optique
US8701784B2 (en) 2011-07-05 2014-04-22 Jonathan V. Huseman Tongs triggering method
US20140177392A1 (en) * 2012-12-21 2014-06-26 Halliburton Energy Services, Inc. Acoustic Reception
US8875785B2 (en) 2012-07-16 2014-11-04 Halliburton Energy Services, Inc. System and method for correcting downhole speed
US8910716B2 (en) 2010-12-16 2014-12-16 Baker Hughes Incorporated Apparatus and method for controlling fluid flow from a formation
US9127532B2 (en) 2011-09-07 2015-09-08 Halliburton Energy Services, Inc. Optical casing collar locator systems and methods
US20170058662A1 (en) * 2015-08-31 2017-03-02 Curtis G. Blount Locating pipe external equipment in a wellbore
US9617829B2 (en) 2010-12-17 2017-04-11 Exxonmobil Upstream Research Company Autonomous downhole conveyance system
US9657540B2 (en) 2012-07-16 2017-05-23 Halliburton Energy Services, Inc. System and method for wireline tool pump-down operations
US9789544B2 (en) 2006-02-09 2017-10-17 Schlumberger Technology Corporation Methods of manufacturing oilfield degradable alloys and related products
US20170298723A1 (en) * 2016-04-14 2017-10-19 Baker Hughes Incorporated Hydraulic Casing Collar Locator
US9909411B2 (en) 2012-08-23 2018-03-06 Intelligent Wellhead Systems Inc. Apparatus and method for sensing a pipe coupler within an oil well structure
US10094213B1 (en) 2017-05-19 2018-10-09 Baker Hughes, A Ge Company, Llc Distributed remote logging
US10185052B2 (en) 2016-12-19 2019-01-22 Baker Hughes, A Ge Company, Llc Constrained backscatter gamma ray casing and cement inspection tool
US10316616B2 (en) 2004-05-28 2019-06-11 Schlumberger Technology Corporation Dissolvable bridge plug
US10415341B2 (en) 2014-07-28 2019-09-17 Baker Hughes, A Ge Company, Llc Downhole system using packer setting joint and method
US10436017B2 (en) 2015-03-31 2019-10-08 Halliburton Energy Services, Inc. Plug tracking using piezo electric pulse signaling
US10648249B2 (en) * 2013-05-11 2020-05-12 Schlumberger Technology Corporation Deployment and retrieval system for electric submersible pumps
US11085289B2 (en) 2017-05-19 2021-08-10 Baker Hughes Holdings Llc Distributed remote logging
US11125076B1 (en) 2020-07-21 2021-09-21 Saudi Arabian Oil Company Accelerometer based casing collar locator
US11215732B2 (en) 2017-09-25 2022-01-04 Baker Hughes Holdings Llc Geological constraint using probability functions in stochastic mineralogy modeling
US11781424B2 (en) 2021-12-15 2023-10-10 Saudi Arabian Oil Company Registering fiber position to well depth in a wellbore
US11885924B2 (en) 2021-12-14 2024-01-30 Halliburton Energy Services, Inc. Locating collars on well casings
US12223016B2 (en) 2021-04-16 2025-02-11 Saudi Arabian Oil Company System and method using machine learning for automated casing and/or tubing inspection log interpretation
US12486762B2 (en) 2024-01-11 2025-12-02 Saudi Arabian Oil Company Systems and methods for untethered wellbore investigation using modular autonomous device

Families Citing this family (41)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2004020789A2 (fr) * 2002-08-30 2004-03-11 Sensor Highway Limited Procede et appareil de diagraphie d'un puits au moyen d'un cable et des capteurs a fibre optique
US6860327B2 (en) * 2002-11-26 2005-03-01 Woodco Usa Pressure containing assembly used to detect the location of anomalies within a blowout preventer (BOP) stack
US7077200B1 (en) * 2004-04-23 2006-07-18 Schlumberger Technology Corp. Downhole light system and methods of use
GB2422622A (en) 2005-01-31 2006-08-02 Pathfinder Energy Services Inc Method For Locating Casing Joints Using A Measurement While Drilling Tool
US7654318B2 (en) * 2006-06-19 2010-02-02 Schlumberger Technology Corporation Fluid diversion measurement methods and systems
US7557492B2 (en) * 2006-07-24 2009-07-07 Halliburton Energy Services, Inc. Thermal expansion matching for acoustic telemetry system
US7595737B2 (en) * 2006-07-24 2009-09-29 Halliburton Energy Services, Inc. Shear coupled acoustic telemetry system
US20090078413A1 (en) * 2007-09-25 2009-03-26 Tubel Paulo S Wireless casing collar locator
US20100309750A1 (en) * 2009-06-08 2010-12-09 Dominic Brady Sensor Assembly
US8455415B2 (en) * 2009-10-23 2013-06-04 Exxonmobil Research And Engineering Company Poly(alpha-olefin/alkylene glycol) copolymer, process for making, and a lubricant formulation therefor
US20110203805A1 (en) * 2010-02-23 2011-08-25 Baker Hughes Incorporated Valving Device and Method of Valving
EP2546456A1 (fr) 2011-07-11 2013-01-16 Welltec A/S Procédé de positionnement
US9234974B2 (en) 2011-09-26 2016-01-12 Saudi Arabian Oil Company Apparatus for evaluating rock properties while drilling using drilling rig-mounted acoustic sensors
US9903974B2 (en) 2011-09-26 2018-02-27 Saudi Arabian Oil Company Apparatus, computer readable medium, and program code for evaluating rock properties while drilling using downhole acoustic sensors and telemetry system
US9447681B2 (en) 2011-09-26 2016-09-20 Saudi Arabian Oil Company Apparatus, program product, and methods of evaluating rock properties while drilling using downhole acoustic sensors and a downhole broadband transmitting system
US10180061B2 (en) 2011-09-26 2019-01-15 Saudi Arabian Oil Company Methods of evaluating rock properties while drilling using downhole acoustic sensors and a downhole broadband transmitting system
US10551516B2 (en) 2011-09-26 2020-02-04 Saudi Arabian Oil Company Apparatus and methods of evaluating rock properties while drilling using acoustic sensors installed in the drilling fluid circulation system of a drilling rig
US9074467B2 (en) * 2011-09-26 2015-07-07 Saudi Arabian Oil Company Methods for evaluating rock properties while drilling using drilling rig-mounted acoustic sensors
US9624768B2 (en) 2011-09-26 2017-04-18 Saudi Arabian Oil Company Methods of evaluating rock properties while drilling using downhole acoustic sensors and telemetry system
EP2607621A1 (fr) * 2011-12-21 2013-06-26 Welltec A/S Système de cartographie de trou de forage
WO2014109754A1 (fr) * 2013-01-11 2014-07-17 Halliburton Energy Services, Inc. Réflectrométrie de suivi temporel en domaine temporel pour la surveillance des tubes de production et des formations
US10247840B2 (en) * 2013-01-24 2019-04-02 Halliburton Energy Services, Inc. Optical well logging
US9608627B2 (en) 2013-01-24 2017-03-28 Halliburton Energy Services Well tool having optical triggering device for controlling electrical power delivery
GB2540081B (en) * 2014-06-05 2020-12-09 Halliburton Energy Services Inc Locating a downhole tool in a wellbore
WO2016032517A1 (fr) 2014-08-29 2016-03-03 Schlumberger Canada Limited Ensemble capteur magnéto-sensible à fibre optique
US10577923B2 (en) 2015-03-20 2020-03-03 Halliburton Energy Services, Inc. Leak detection via doppler shift differences in moving hydrophones
US20180230799A1 (en) * 2015-10-08 2018-08-16 Halliburton Energy Services, Inc. Communication to a downhole tool by acoustic waveguide transfer
US20170138181A1 (en) * 2015-11-16 2017-05-18 Sure Shot Wireline Inc. Method and system for logging a well
US10253622B2 (en) * 2015-12-16 2019-04-09 Halliburton Energy Services, Inc. Data transmission across downhole connections
US10683745B2 (en) * 2016-11-25 2020-06-16 Intelligent Wellhead Systems Inc. Apparatus and method for preventing collisions while moving tubulars into and out of a wellhead
US20180298747A1 (en) * 2017-04-18 2018-10-18 General Electric Company System and method for monitoring positions of pipe joints in production system
US11525349B2 (en) 2017-08-08 2022-12-13 Halliburton Energy Services, Inc. Workflow and visualization for localization of concentric pipe collars
US10955264B2 (en) 2018-01-24 2021-03-23 Saudi Arabian Oil Company Fiber optic line for monitoring of well operations
CN109184673B (zh) * 2018-11-12 2023-11-24 美钻深海能源科技研发（上海）有限公司 一种机械式管柱接箍检测装置及方法
US10995574B2 (en) 2019-04-24 2021-05-04 Saudi Arabian Oil Company Subterranean well thrust-propelled torpedo deployment system and method
US11365958B2 (en) * 2019-04-24 2022-06-21 Saudi Arabian Oil Company Subterranean well torpedo distributed acoustic sensing system and method
US10883810B2 (en) 2019-04-24 2021-01-05 Saudi Arabian Oil Company Subterranean well torpedo system
CA3171315A1 (fr) 2020-02-14 2021-08-19 Hunting Titan, Inc. Unite panneau de perforation et procede
US11867051B2 (en) 2020-02-20 2024-01-09 Baker Hughes Oilfield Operations Llc Incremental downhole depth methods and systems
CN112267871B (zh) * 2020-10-16 2024-08-13 无锡智瀚能源科技装备与服务有限公司 管杆接箍检测装置和包括该装置的绞车控制系统、修井机
CN115749700A (zh) * 2022-11-17 2023-03-07 宝鸡文理学院 电子气举柱塞

Citations (20)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2547875A (en) 1936-10-29 1951-04-03 Schlumberger Well Surv Corp Apparatus for taking physical measurements in boreholes
US2888309A (en) 1955-10-07 1959-05-26 Schlumberger Well Surv Corp Memorizing system
US2897440A (en) 1955-04-12 1959-07-28 Dresser Ind Earth well casing discontinuity detector
US3381750A (en) 1965-10-21 1968-05-07 Otis Eng Co Apparatus for signaling the location of recesses in a flow conductor
US3750098A (en) * 1970-11-13 1973-07-31 Schlumberger Technology Corp Downhole acoustic logging control system
US3821696A (en) 1973-03-13 1974-06-28 Mobil Oil Downhole data generator for logging while drilling system
US4216536A (en) 1978-10-10 1980-08-05 Exploration Logging, Inc. Transmitting well logging data
US4314365A (en) 1980-01-21 1982-02-02 Exxon Production Research Company Acoustic transmitter and method to produce essentially longitudinal, acoustic waves
US4852070A (en) 1986-06-19 1989-07-25 Halliburton Logging Services, Inc. Method and apparatus for transmitting and processing data from well logging tool
US4992997A (en) 1988-04-29 1991-02-12 Atlantic Richfield Company Stress wave telemetry system for drillstems and tubing strings
US5279366A (en) * 1992-09-01 1994-01-18 Scholes Patrick L Method for wireline operation depth control in cased wells
US5413174A (en) * 1994-05-18 1995-05-09 Atlantic Richfield Company Signal transmission through deflected well tubing
US5429190A (en) 1993-11-01 1995-07-04 Halliburton Company Slick line casing and tubing joint locator apparatus and associated methods
EP0697497A1 (fr) 1994-08-18 1996-02-21 Halliburton Company Appareil pour localiser des joints dans un puits
US5494105A (en) 1994-10-25 1996-02-27 Camco International Inc. Method and related system for operating a downhole tool
US5626192A (en) 1996-02-20 1997-05-06 Halliburton Energy Services, Inc. Coiled tubing joint locator and methods
US5774420A (en) 1995-08-16 1998-06-30 Halliburton Energy Services, Inc. Method and apparatus for retrieving logging data from a downhole logging tool
US5947213A (en) 1996-12-02 1999-09-07 Intelligent Inspection Corporation Downhole tools using artificial intelligence based control
US6041860A (en) 1996-07-17 2000-03-28 Baker Hughes Incorporated Apparatus and method for performing imaging and downhole operations at a work site in wellbores
US6237410B1 (en) * 1996-10-07 2001-05-29 Circa Enterprises Inc. Method for controlling the speed of a pump based on measurement of the fluid depth in a well

Family Cites Families (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6253842B1 (en) * 1998-09-01 2001-07-03 Halliburton Energy Services, Inc. Wireless coiled tubing joint locator

Patent Citations (20)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2547875A (en) 1936-10-29 1951-04-03 Schlumberger Well Surv Corp Apparatus for taking physical measurements in boreholes
US2897440A (en) 1955-04-12 1959-07-28 Dresser Ind Earth well casing discontinuity detector
US2888309A (en) 1955-10-07 1959-05-26 Schlumberger Well Surv Corp Memorizing system
US3381750A (en) 1965-10-21 1968-05-07 Otis Eng Co Apparatus for signaling the location of recesses in a flow conductor
US3750098A (en) * 1970-11-13 1973-07-31 Schlumberger Technology Corp Downhole acoustic logging control system
US3821696A (en) 1973-03-13 1974-06-28 Mobil Oil Downhole data generator for logging while drilling system
US4216536A (en) 1978-10-10 1980-08-05 Exploration Logging, Inc. Transmitting well logging data
US4314365A (en) 1980-01-21 1982-02-02 Exxon Production Research Company Acoustic transmitter and method to produce essentially longitudinal, acoustic waves
US4852070A (en) 1986-06-19 1989-07-25 Halliburton Logging Services, Inc. Method and apparatus for transmitting and processing data from well logging tool
US4992997A (en) 1988-04-29 1991-02-12 Atlantic Richfield Company Stress wave telemetry system for drillstems and tubing strings
US5279366A (en) * 1992-09-01 1994-01-18 Scholes Patrick L Method for wireline operation depth control in cased wells
US5429190A (en) 1993-11-01 1995-07-04 Halliburton Company Slick line casing and tubing joint locator apparatus and associated methods
US5413174A (en) * 1994-05-18 1995-05-09 Atlantic Richfield Company Signal transmission through deflected well tubing
EP0697497A1 (fr) 1994-08-18 1996-02-21 Halliburton Company Appareil pour localiser des joints dans un puits
US5494105A (en) 1994-10-25 1996-02-27 Camco International Inc. Method and related system for operating a downhole tool
US5774420A (en) 1995-08-16 1998-06-30 Halliburton Energy Services, Inc. Method and apparatus for retrieving logging data from a downhole logging tool
US5626192A (en) 1996-02-20 1997-05-06 Halliburton Energy Services, Inc. Coiled tubing joint locator and methods
US6041860A (en) 1996-07-17 2000-03-28 Baker Hughes Incorporated Apparatus and method for performing imaging and downhole operations at a work site in wellbores
US6237410B1 (en) * 1996-10-07 2001-05-29 Circa Enterprises Inc. Method for controlling the speed of a pump based on measurement of the fluid depth in a well
US5947213A (en) 1996-12-02 1999-09-07 Intelligent Inspection Corporation Downhole tools using artificial intelligence based control

Non-Patent Citations (2)

* Cited by examiner, † Cited by third party
Title
"A New Method for Communicating Downhole Sensor Data Within the Annulus of a Production Well"; Authors: J. V. Leggett III & B. R. Green, Society of Petroleum Engineers 28522; SPE 69<SUP>th </SUP>Annual Technical Conference & Exhibition, New Orleans, LA, Sept. 25-28, 1994; pp. 33-42.
"Method and Apparatus for Improved Acoustic Coupling for Acoustic Signal Communication in a Wellbore", Research Disclosure, May 1999, 622-625.

Cited By (70)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20050173639A1 (en) * 1999-12-23 2005-08-11 Frederick Larry D. Geosteering of solid mineral mining machines
US7402804B2 (en) * 1999-12-23 2008-07-22 Geosteering Mining Services, Llc Geosteering of solid mineral mining machines
US20040246141A1 (en) * 2003-06-03 2004-12-09 Tubel Paulo S. Methods and apparatus for through tubing deployment, monitoring and operation of wireless systems
US7257050B2 (en) * 2003-12-08 2007-08-14 Shell Oil Company Through tubing real time downhole wireless gauge
US20050121253A1 (en) * 2003-12-08 2005-06-09 John Stewart Through tubing real time downhole wireless gauge
US20060081380A1 (en) * 2003-12-15 2006-04-20 Hoffman Corey E Collar locator for slick pump
US7600566B2 (en) * 2003-12-15 2009-10-13 Weatherford/Lamb, Inc. Collar locator for slick pump
US10316616B2 (en) 2004-05-28 2019-06-11 Schlumberger Technology Corporation Dissolvable bridge plug
US7140434B2 (en) * 2004-07-08 2006-11-28 Schlumberger Technology Corporation Sensor system
US20060005965A1 (en) * 2004-07-08 2006-01-12 Christian Chouzenoux Sensor system
US20060157250A1 (en) * 2004-12-23 2006-07-20 Remote Marine Systems Limited Improvements In or Relating to Sub Sea Control and Monitoring
US7650942B2 (en) * 2004-12-23 2010-01-26 Remote Marine Systems Limited Sub sea control and monitoring system
US20070044958A1 (en) * 2005-08-31 2007-03-01 Schlumberger Technology Corporation Well Operating Elements Comprising a Soluble Component and Methods of Use
US8567494B2 (en) 2005-08-31 2013-10-29 Schlumberger Technology Corporation Well operating elements comprising a soluble component and methods of use
US9982505B2 (en) 2005-08-31 2018-05-29 Schlumberger Technology Corporation Well operating elements comprising a soluble component and methods of use
US9789544B2 (en) 2006-02-09 2017-10-17 Schlumberger Technology Corporation Methods of manufacturing oilfield degradable alloys and related products
US8220554B2 (en) 2006-02-09 2012-07-17 Schlumberger Technology Corporation Degradable whipstock apparatus and method of use
US7588083B2 (en) 2006-03-27 2009-09-15 Key Energy Services, Inc. Method and system for scanning tubing
WO2007112363A3 (fr) * 2006-03-27 2008-05-08 Key Energy Services Inc Procédés et système d'évaluation et d'affichage de données de profondeur
US7571054B2 (en) 2006-03-27 2009-08-04 Key Energy Services, Inc. Method and system for interpreting tubing data
US20080035335A1 (en) * 2006-03-27 2008-02-14 Newman Frederic M Method and system for evaluating and displaying depth data
US20080035333A1 (en) * 2006-03-27 2008-02-14 Newman Frederic M Method and system for scanning tubing
US7672785B2 (en) 2006-03-27 2010-03-02 Key Energy Services, Inc. Method and system for evaluating and displaying depth data
US7788054B2 (en) 2006-03-28 2010-08-31 Key Energy Services, Llc Method and system for calibrating a tube scanner
US20070227225A1 (en) * 2006-03-28 2007-10-04 Newman Frederic M Method and system for calibrating a tube scanner
US8183163B2 (en) 2006-09-12 2012-05-22 Kabushiki Kaisha Toshiba Etching liquid, etching method, and method of manufacturing electronic component
US20080257546A1 (en) * 2006-09-20 2008-10-23 Baker Hughes Incorporated Autonomous Downhole Control Methods and Devices
US8899322B2 (en) * 2006-09-20 2014-12-02 Baker Hughes Incorporated Autonomous downhole control methods and devices
US8878688B2 (en) * 2006-10-12 2014-11-04 Antech Limited Well downhole condition signalling
US20080089175A1 (en) * 2006-10-12 2008-04-17 Antech Limited Well downhole condition signalling
US20080164025A1 (en) * 2007-01-10 2008-07-10 Baker Hughes Incorporated System and Method for Determining the Rotational Alignment of Drillstring Elements
US7814988B2 (en) 2007-01-10 2010-10-19 Baker Hughes Incorporated System and method for determining the rotational alignment of drillstring elements
US7762327B2 (en) * 2008-07-03 2010-07-27 Vetco Gray Inc. Acoustically measuring annulus probe depth
US20100000730A1 (en) * 2008-07-03 2010-01-07 Vetco Gray Inc. Acoustically Measuring Annulus Probe Depth
US20110290011A1 (en) * 2008-10-03 2011-12-01 Najmud Dowla Identification of casing collars while drilling and post drilling using lwd and wireline measurements
US9175559B2 (en) * 2008-10-03 2015-11-03 Schlumberger Technology Corporation Identification of casing collars while drilling and post drilling using LWD and wireline measurements
US20110083845A1 (en) * 2009-10-09 2011-04-14 Impact Guidance Systems, Inc. Datacoil™ Downhole Logging System
US8469107B2 (en) 2009-12-22 2013-06-25 Baker Hughes Incorporated Downhole-adjustable flow control device for controlling flow of a fluid into a wellbore
US20110147007A1 (en) * 2009-12-22 2011-06-23 Baker Hughes Incorporated Downhole-Adjustable Flow Control Device for Controlling Flow of a Fluid Into a Wellbore
US8910716B2 (en) 2010-12-16 2014-12-16 Baker Hughes Incorporated Apparatus and method for controlling fluid flow from a formation
EA030072B1 (ru) * 2010-12-17 2018-06-29 Эксонмобил Апстрим Рисерч Компани Способ автоматического управления и позиционирования автономных скважинных инструментов
US9328578B2 (en) 2010-12-17 2016-05-03 Exxonmobil Upstream Research Company Method for automatic control and positioning of autonomous downhole tools
WO2012082302A1 (fr) * 2010-12-17 2012-06-21 Exxonmobil Upstream Research Company Procédé de commande et de positionnement automatiques d'outils autonomes de fond de trou
US9617829B2 (en) 2010-12-17 2017-04-11 Exxonmobil Upstream Research Company Autonomous downhole conveyance system
US8701784B2 (en) 2011-07-05 2014-04-22 Jonathan V. Huseman Tongs triggering method
WO2013036852A1 (fr) * 2011-09-07 2013-03-14 Halliburgton Energy Services, Inc. Systèmes et procédés de localisateur de joints de tubage optique
US9127532B2 (en) 2011-09-07 2015-09-08 Halliburton Energy Services, Inc. Optical casing collar locator systems and methods
US9127531B2 (en) 2011-09-07 2015-09-08 Halliburton Energy Services, Inc. Optical casing collar locator systems and methods
US8875785B2 (en) 2012-07-16 2014-11-04 Halliburton Energy Services, Inc. System and method for correcting downhole speed
US9657540B2 (en) 2012-07-16 2017-05-23 Halliburton Energy Services, Inc. System and method for wireline tool pump-down operations
US9909411B2 (en) 2012-08-23 2018-03-06 Intelligent Wellhead Systems Inc. Apparatus and method for sensing a pipe coupler within an oil well structure
US10221678B2 (en) 2012-08-23 2019-03-05 Intelligent Wellhead Systems Inc. Apparatus and method for measuring a pipe within an oil well structure
US9019798B2 (en) * 2012-12-21 2015-04-28 Halliburton Energy Services, Inc. Acoustic reception
US20140177392A1 (en) * 2012-12-21 2014-06-26 Halliburton Energy Services, Inc. Acoustic Reception
US10648249B2 (en) * 2013-05-11 2020-05-12 Schlumberger Technology Corporation Deployment and retrieval system for electric submersible pumps
US10415341B2 (en) 2014-07-28 2019-09-17 Baker Hughes, A Ge Company, Llc Downhole system using packer setting joint and method
US10436017B2 (en) 2015-03-31 2019-10-08 Halliburton Energy Services, Inc. Plug tracking using piezo electric pulse signaling
US20170058662A1 (en) * 2015-08-31 2017-03-02 Curtis G. Blount Locating pipe external equipment in a wellbore
US9890631B2 (en) * 2016-04-14 2018-02-13 Baker Hughes, A Ge Company, Llc Hydraulic casing collar locator
US20170298723A1 (en) * 2016-04-14 2017-10-19 Baker Hughes Incorporated Hydraulic Casing Collar Locator
US10185052B2 (en) 2016-12-19 2019-01-22 Baker Hughes, A Ge Company, Llc Constrained backscatter gamma ray casing and cement inspection tool
US10094213B1 (en) 2017-05-19 2018-10-09 Baker Hughes, A Ge Company, Llc Distributed remote logging
US10975690B2 (en) 2017-05-19 2021-04-13 Baker Hughes Holdings Llc Distributed remote logging
US11085289B2 (en) 2017-05-19 2021-08-10 Baker Hughes Holdings Llc Distributed remote logging
US11215732B2 (en) 2017-09-25 2022-01-04 Baker Hughes Holdings Llc Geological constraint using probability functions in stochastic mineralogy modeling
US11125076B1 (en) 2020-07-21 2021-09-21 Saudi Arabian Oil Company Accelerometer based casing collar locator
US12223016B2 (en) 2021-04-16 2025-02-11 Saudi Arabian Oil Company System and method using machine learning for automated casing and/or tubing inspection log interpretation
US11885924B2 (en) 2021-12-14 2024-01-30 Halliburton Energy Services, Inc. Locating collars on well casings
US11781424B2 (en) 2021-12-15 2023-10-10 Saudi Arabian Oil Company Registering fiber position to well depth in a wellbore
US12486762B2 (en) 2024-01-11 2025-12-02 Saudi Arabian Oil Company Systems and methods for untethered wellbore investigation using modular autonomous device

Also Published As

Publication number Publication date
CA2448895A1 (fr) 2002-12-12
GB2393201B (en) 2006-01-11
CA2448895C (fr) 2008-01-15
NO20035271D0 (no) 2003-11-27
GB2393201A (en) 2004-03-24
GB0327309D0 (en) 2003-12-24
WO2002099250A1 (fr) 2002-12-12
US20030010495A1 (en) 2003-01-16
AU2002313629B2 (en) 2008-02-07

Similar Documents

Publication Publication Date Title
US6896056B2 (en) System and methods for detecting casing collars
AU2002313629A1 (en) Systems and methods for detecting casing collars
US6915849B2 (en) Apparatus and methods for conveying instrumentation within a borehole using continuous sucker rod
CA2473495C (fr) Systeme et procede permettant de realiser de maniere autonome une operation de puits de fond
US6736210B2 (en) Apparatus and methods for placing downhole tools in a wellbore
US5509474A (en) Temperature logging for flow outside casing of wells
US8016036B2 (en) Tagging a formation for use in wellbore related operations
US7073582B2 (en) Method and apparatus for positioning a downhole tool
US7475732B2 (en) Instrumentation for a downhole deployment valve
US7389183B2 (en) Method for determining a stuck point for pipe, and free point logging tool
US6644402B1 (en) Method of installing a sensor in a well
CN1346555A (zh) 确定管子中位置的方法和装置
WO2008014039A2 (fr) Système permettant de communiquer des informations de fond par un puits de forage jusqu&#39;à un emplacement en surface
US7770639B1 (en) Method for placing downhole tools in a wellbore
WO2009004336A1 (fr) Indicateur de position inertielle
CA2509603C (fr) Bouchon separable pour utilisation avec un outil de puits de forage
GB2410279A (en) Method for detecting casing collars
GB2443374A (en) Instrumentation for downhole deployment valve

Legal Events

Date Code Title Description
AS Assignment

Owner name: BAKER HUGHES INCORPORATED, TEXAS

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:MENDEZ, LUIS;BRIDGES, JAMES R.;WILLAUER, DARRIN;REEL/FRAME:013296/0266;SIGNING DATES FROM 20020725 TO 20020903

FPAY Fee payment

Year of fee payment: 4

REMI Maintenance fee reminder mailed
LAPS Lapse for failure to pay maintenance fees
STCH Information on status: patent discontinuation

Free format text: PATENT EXPIRED DUE TO NONPAYMENT OF MAINTENANCE FEES UNDER 37 CFR 1.362

STCH Information on status: patent discontinuation

Free format text: PATENT EXPIRED DUE TO NONPAYMENT OF MAINTENANCE FEES UNDER 37 CFR 1.362

FP Lapsed due to failure to pay maintenance fee

Effective date: 20130524